Day 1 Mon, October 03, 2022最新文献

{"title":"Rock Physics and Machine Learning Analysis of a High-Porosity Gas Sand in the Gulf of Mexico","authors":"V. Suleymanov, A. El-Husseiny, G. Glatz, J. Dvorkin","doi":"10.2118/210191-ms","DOIUrl":"https://doi.org/10.2118/210191-ms","url":null,"abstract":"\u0000 Rock physics transforms established on the well data play an important role in predicting seismic rock properties. However, a data-driven approach, such as machine learning, can also estimate the targeted outputs from the well data. This study aims at comparing the accuracy of rock physics and machine learning analyses for the prediction of the P-wave velocity of porous rocks at the well log scale by employing the well data from the Mississippi Canyon, Gulf of Mexico.\u0000 Rock physics diagnostics (RPD) was used as a physics-driven methodology for predicting the P-wave velocity, while artificial neural network (ANN) was used as a machine learning approach. To train the neural network, the well data were divided into two sections where the ANN model was optimized on the upper well data interval and tested in the lower interval. During the rock physics analysis, the lower interval was employed to compare the obtained results from the physics-driven and data-driven approaches in the same well interval.\u0000 Based on the results from RPD, the constant cement model with a high coordination number describes the well data under examination. The established rock physics model is used for predicting elastic properties of rocks, including the P-wave velocity from measured petrophysical properties, namely porosity, mineralogy, and the pore fluid. However, the mineralogy input, such as the clay content, was missing in the well data. Therefore, the clay content was calculated from the gamma ray log and used in the rock physics model established. On the other hand, the ANN model was developed and tested using well log inputs such as porosity, gamma ray, and resistivity logs. Results showed that the accuracy of the machine learning model outperforms that of the rock physics model in the prediction of the P-wave velocity. In particular, a correlation coefficient (R) of 0.84 and absolute average percentage error (AAPE) of 2.71 were obtained by the ANN model, while the constant cement model reached CC of 0.65 and AAPE of 4.07. However, one should be aware that the computed clay content from the gamma ray log was a major factor in obtaining low CC compared to the ANN model as it significantly introduced uncertainty in our computations.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"102 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115689315","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Design and Implementation of Field Tests in Unconventional Reservoirs: Practical Perspectives","authors":"M. McClure, Maggie Albrecht, C. Cipolla, Claudia Molina","doi":"10.2118/210477-ms","DOIUrl":"https://doi.org/10.2118/210477-ms","url":null,"abstract":"\u0000 Optimizing the development of unconventional resources is a complex process, with significant uncertainty in reservoir characterization, completion effectiveness, and drainage efficiency. The primary parameters in the optimization are: stage length, cluster spacing, fluid type and volume, proppant type and loading, well spacing, landing zone(s), and lateral length. To improve over time, operators: evaluate alternatives, trial new designs, evaluate results, and iterate. This paper provides perspectives from industry practitioners on this process. It discusses: (a) defining objectives, (b) integrating information, (c) evaluating alternatives, (d) designing field trials, (e) evaluating outcomes, and (f) maximizing the value of field trials with diagnostic data collection.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"21 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127497434","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Improving Alkali Polymer Flooding Economics by Capitalizing on Polymer Solution Property Evolution at High pH","authors":"L. Nurmi, R. Hincapie, T. Clemens, S. Hanski, Ante Borovina, H. Födisch, A. Janczak","doi":"10.2118/210043-ms","DOIUrl":"https://doi.org/10.2118/210043-ms","url":null,"abstract":"\u0000 Alkali Polymer (AP) flooding is a promising Enhanced Oil Recovery (EOR) method to increase oil recovery from reactive oils. It is essential to carefully select the alkali and polymer type and concentration to optimize incremental oil recovery. In addition to the conventional laboratory tests for polymer flooding, the effects of the high pH on the polymer and its evolving properties over time need to be investigated. Consideration of near-wellbore and reservoir effects is a key in designing the process. We are showing how understanding and taking advantage of the polymer performance in a high pH environment allows to reduce costs, increase injectivity and incremental oil recovery for AP projects.\u0000 The polymer performance was evaluated for AP flooding of the Matzen field (Austria). Evaluations included changes in polymer rheology during aging at high pH conditions, phase behavior tests, and single/two-phase core floods with aged and non-aged polymer solutions. In addition, adsorption of the aged polymer and interfacial tension was measured. The aging was studied in anaerobic conditions at reservoir temperature and through an accelerated method at elevated temperature. The degree of polymer hydrolysis over time was determined via NMR and linked to viscosity performance.\u0000 The AP conditions in the Matzen AP flooding project (pH > 10) lead to an increased initial rate of polymer hydrolysis of the tested HPAM by a factor of 100 compared to hydrolysis at a neutral pH level. This resulted in a rapid increase in polymer solution viscosity of 160 % compared with initial conditions within days at reservoir temperature of 49 °C, after which the increase leveled off. Accelerated aging experiments at higher temperature predict long-term stability of the increased viscosity level for several years. Single-phase injection test in representative core confirmed the performance of the aged solution compared to a non-aged solution at the same polymer concentration. The retention of polymers is reduced in AP conditions compared with traditional neutral pH conditions. Two-phase core flood tests showed the increased polymer viscosity at reservoir conditions. The displacement efficiency of the aged and non-aged polymer solution was similar confirming the potential for cost savings using lower polymer concentration and making use of the increased polymer viscosity owing to hydrolysis.\u0000 The results show that the design of alkali polymer projects needs to take the changing polymer rheology with time into account. The costs of alkali polymer projects can be reduced owing to the lower required polymer concentrations for the same displacement efficiency and reduced retention of polymer. An efficient design of alkali polymer projects takes good injectivity of non-aged polymers and the aging of the polymer solutions in alkali into account.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"23 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114484618","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Effect of Supercritical CO2 on the Poroelastic Characteristics of Poorly Cemented Sandstone Reservoirs During Depletion and Injection","authors":"S. Hashemi, A. Kovscek, M. Zoback","doi":"10.2118/210228-ms","DOIUrl":"https://doi.org/10.2118/210228-ms","url":null,"abstract":"\u0000 While there is continuing interest in geologic CO2 storage, experimental studies on poroelastic characteristics of reservoir rocks during depletion and subsequent CO2 injection are scarce. Rock stiffness, confining stress, and pore pressure control the poroelastic response of saturated rocks. Also, the stress and pore pressure evolution during injection is a key parameter to understanding operations thresholds for CO2 storage projects. As depleted fields in the Gulf of Mexico have been identified as strong candidates for CO2 storage projects, it is important to understand if the poroelastic characteristics from such fields have been altered due to depletion. Among rock properties, Young’s modulus (E), bulk modulus (Kb) and Biot coefficient (α) are of particular importance.\u0000 In this study, the poroelastic deformation of a core from the West Delta field in the Gulf of Mexico is characterized experimentally and the impacts of supercritical CO2 (scCO2) on the specimen are investigated. The experimental program simulated reservoir stress changes due to production-induced depletion and scCO2 injection through cycling both the confining pressure (Cp) and pore pressure (Pp). We measured the deviatoric stress, volumetric strain, derived the corresponding Young’s (E), bulk moduli (Kb) and Biot coefficient (α). The results show that the effect of scCO2 on E is more significant at greater confining pressures during the injection phase than depletion at a constant simple effective stress. Interaction of scCO2 with clay minerals caused rock frame dehydration and led to an increase in E. The bulk modulus increased with increasing the confining pressure at a given Pp and decreased with Pp at a certain Cp. α rose with Pp during both depletion and injection phases. Interaction with scCO2 limited the variation of α and the effect of Pp and Cp on α decreased in significance during the depletion phase. Longer interaction time with scCO2 increased α from 10-25% at different Pp values compared to argon during the injection stage. However, the influence of effective stress in reducing the α weakened.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"53 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128333514","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Correlated Inversion of Complex Dielectric Dispersion and NMR Measurements in Conventional Carbonates","authors":"J. Funk, M. Myers, L. Hathon","doi":"10.2118/210006-ms","DOIUrl":"https://doi.org/10.2118/210006-ms","url":null,"abstract":"\u0000 Combinations of dielectric and NMR measurements are frequently used to improve saturation modeling in complex situations, often incorporating the concept of wettability. Due to the two methods' distinct tools and physical mechanisms, the interplay of the electrical and magnetic fields and their constitutive equations are generally not addressed. This is directly counter to the situation with the medical imaging modalities, magnetic resonance electrical properties tomography (MREPT) and magnetic resonance electrical impedance tomography (MREIT), where field-specific polarizations and relaxations are used to enhance the contrast.\u0000 Both electrical and magnetic (EM) fields at the frequencies typically encountered in laboratory and logging environments impart molecular motions impacted by pore structure. In both instances, restricted motions are reflected in their individual responses' time or frequency domain. Using time-domain relaxations and variations in both EM fields, this work focuses on the practicality of using NMR and dielectric relaxation comparisons originally proposed by Bloembergen, Purcell, and Pound (BPP). Similar to the dipolar relaxation equivalence in the BPP model, we develop a relaxation time correlation assuming representative Maxwell-Wagner relaxations for the key pore components demonstrated by Myers.\u0000 The distributions of dielectric relaxation times evident in carbonate dispersion curves from 1 – 300 MHz were quantified using the Havriliak-Negami (HN) model. The quantifications are then used to evaluate characteristic dielectric dispersions curves generated from a dielectric model introducing multiple pore systems in carbonates. The modeled distributions are spectrally mapped to the NMR T2 distributions based on Debye shielding distances correlated with the conductivity. The interplay of pore connectivity and surface and bulk diffusivity are modeled using a \"two-fraction fast exchange model\" by Brownstein and Tarr.\u0000 Using dielectric and NMR experiments along with a combination of micro-CT and SEM imaging techniques, the NMR-based spectral distribution of dielectric relaxation times demonstrates that variable-length scales and fractal dimensions accessed through the dielectric dispersion measurements are more extensive than that implied by the standard reference to the \"texture\" of a carbonate sample. We also show that the modeled distributions are closely correlated with the conductivity and provide improved petrophysical insight for the frequently used Archie exponent combination (MN) associated with the water tortuosity.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128461382","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Finding the Right Concept Via a Decision Quality Framework with Rapid Generation of Multiple Deepwater Conceptual Alternatives","authors":"Y. Zeng, S. Ryu, C. Chaney, A. Hill, W. Sun, B. Keinath, C. E. Osuji, D. Sistiva, S. Ford, H. Stripling, L. Garza-Rios, S. Kim, B. Ruskin, L. Basilio, P. B. Machado, R. Castro, J. Bickel","doi":"10.2118/210288-ms","DOIUrl":"https://doi.org/10.2118/210288-ms","url":null,"abstract":"\u0000 The key to finding the highest-value concept in deepwater full-field development is by making high-quality decisions during the Concept Select stage of a project. One of the critical elements to achieve this is by considering a broad range of conceptual alternatives and evaluating them rapidly, providing timely feedback, and facilitating an exploratory learning process. However, concept-select decisions are challenged by competing objectives, significant uncertainties, and many possible concepts. Further, deepwater full-field developments require strong connectivity and interfaces across multiple disciplines, which include reservoir, wells, drilling, flow assurance, subsea, flowlines, risers, topsides, metocean, geotechnical, marine, costing, and project economics.\u0000 Key challenges to the current methodology include a lack of capacity to consider multiple concepts, slow evaluation turn-around for each concept generated, continuous evaluation and revisions with new data and information, lack of ability to integrate processes across multiple disciplines, and poor risk management driven by technical/commercial uncertainties and unavailable data. This paper addresses these challenges by combining concepts from the Decision Quality (DQ) framework and FLOCO® (Field Layout Concept Optimizer), which is a metaheuristic model-based system-engineering software, to efficiently identify the highest value field development concepts among several possible alternatives.\u0000 This novel approach applies a new framework to an offshore deepwater full-field development. Specifically, we explore the trade-space, evaluate the trade-offs between risk and reward, perform integrated techno-economic analysis, and identify the best concepts. Key outputs are the identification of development concepts that meet the given constraints and functional requirements for further optimization, while eliminating those that do not meet such requirements.\u0000 The results demonstrate that the challenges in the current Concept Select phase can be simplified and that the proposed approach offers a quick, logical, and insightful means of selecting the highest-value concept. The case study demonstrates that the proposed improvement to the concept-select stage of deepwater full-field development process can lead to significantly improved project economics, as it fully explores the decision-space, key uncertainties, multiple technically feasible concepts, and key performance indicators such as net present value (NPV) and capital expenditures (CAPEX).\u0000 This paper addresses the development of economic oil and gas projects through decision making enhanced by rapid digital prototyping and analysis. The integration of Decision Quality methodologies with systems-engineering decision-support tools is novel and is likely to become more important as the industry explores and develops more complicated targets in the future.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"23 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129332428","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Adapting Petroleum Reservoir Engineering Principles to Carbon Capture & Sequestration (CCS) and Hydrogen Underground Storage (HUS) Projects: Opportunities and Challenges","authors":"Srikanta Mishra, A. Datta-Gupta","doi":"10.2118/210372-ms","DOIUrl":"https://doi.org/10.2118/210372-ms","url":null,"abstract":"\u0000 Carbon Capture and Sequestration (CCS), which combines capture of CO2 from large stationary sources with geological storage, has emerged as an attractive option for emissions reduction. Hydrogen underground storage (HUS) is viewed as an effective strategy for storing large volumes of surplus electrical energy from renewable sources. The objective of this paper is to discuss the opportunities and challenges for adapting petroleum reservoir engineering techniques for the subsurface aspects of CCS and HUS projects based on a critical review of field projects and conceptual studies. Areas of focus include: (a) storage resource estimation, injectivity analysis from field data, dynamic reservoir modeling, and coupled flow and geomechanics for CCS, and (b) well deliverability, dynamics of fluid withdrawal and reactive transdport of hydrogen in-situ for HUS projects. Specifically, our goal is to discuss how traditional workflows for oil and gas applications have been (or could be) modified for CCS projects in deep saline formations and HUS projects in salt caverns or aquifers. We also identify specific areas where reservoir engineering practitioners can add value in CCS and HUS related reservoir analysis and modeling.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"8 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130373689","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"High-Resolution Resistivity Image Interpretation to Improve Stratigraphic Model of the ITT Field – Oriente Basin, Ecuador","authors":"J. Gaibor, Santiago Guerrero, Martina Grefa, A. Valdez, Á. Villavicencio","doi":"10.2118/210088-ms","DOIUrl":"https://doi.org/10.2118/210088-ms","url":null,"abstract":"\u0000 The Oriente Basin is an oil-rich province located in Ecuador, where the main reservoirs were deposited during the Late Cretaceous. The distribution and thickness of the sandy reservoirs vary from East to West of the basin. For that, most of the reservoirs are amalgamated to the East and the definition of the contacts between them are difficult. The ITT oil field is located in this area and the main reservoir correspond to M1 Sandstone Member of the Napo Formation. However, in certain areas, the contact between M1 Sandstone Member of Napo Formation and the Basal Tena Member of the Tena Formation is hard to discern. The primary objective of this study was determined if the sandstones beds present in the well TMB-081 of the ITT oil field in the Oriente Basin- Ecuador belong to the same formation or not, based on analysis of high-resolution, resistivity-based borehole images.\u0000 The structural analysis of the image show that the sandy interval to the top of the well is in the same structural zone, which suggest that they were deposited in the same sedimentological conditions. Additionally, the sedimentological analysis shows that textures of the image can be linked with lithofacies defined for deltaic environment in previous works. Finally, the paleocurrents direction suggest that the sediments source rock was located to the South and East of the ITT Field.\u0000 The contact between Napo and Tena formations is a regional discordance. Therefore, if all sandy interval is in a single structural zone meaning that they belong to the same formation. Additionally, the direction of the paleocurrent suggest that the origin of the sediments is the Amazonian Craton and not the Andes for these sandstones. In conclusion, the sandstones located to the top of the well TMB-081 correspond to the M1 Sandstone and not to the Basal Tena Sandstone. This definition only can be defined using high-resolution resistivity-based images because the conventional logs can provide this type of information.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"74 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123198031","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Novel Expanding Metal Alloy for Non-Elastomeric Sealing and Anchoring","authors":"M. Fripp, R. Evers, S. Greci, B. Least, Christopher Pelto, Christopher Rodriguez, T. Stein, Lori Wiltz, Allan Zhong","doi":"10.2118/210273-ms","DOIUrl":"https://doi.org/10.2118/210273-ms","url":null,"abstract":"\u0000 A new class of expanding isolation systems has been enabled by the creation of a uniquely engineered expanding metal alloy. The engineered metal alloy expands downhole and chemically transforms from a metal alloy into a rock-like seal. This novel metal alloy results in a sealing system that combines the operational simplicity of swellable elastomers with the robustness of non-elastomeric seals and includes an anchoring capability to the seal.\u0000 Swellable elastomers have provided effective zonal isolation since their introduction in the early 2000s. Swellable elastomers expand by absorbing fluids within the matrix of the elastomer. This absorption causes the swellable elastomer to expand in size and results in a high-pressure seal for zonal isolation. Despite the widespread success of swellable packers, for some applications a non-elastomeric seal for zonal isolation is preferred and more reliable. Applications benefit from non-elastomeric seals for zonal isolation due to temperature, pressure, or chemical compatibility reasons. Other applications, such as fluid injection operations, require anchoring capabilities which can be challenging with swellable elastomers. The new engineered metal alloy chemically reacts with the downhole water-based fluids and expands into a strong rock-like material that provides non-elastomeric zonal isolation with pressure and anchoring capabilities exceeding swellable technology at higher expansion ratios. In addition, water swellable elastomers are not suitable for applications which have a high salinity brine or produced water as the setting fluid. By contrast the expanding metal alloy chemical reaction is enhanced by increasing salinity.\u0000 The expanding metal alloy bonds with the water-based fluid in the wellbore and this chemical reaction causes the metal to expand into a rock-like material. The chemical reaction results in a new material that is larger than the original alloy. Unlike a swellable elastomer which absorbs fluids (a purely physical process governed by thermodynamics and osmosis), the metal alloy's molecular structure chemically transforms, incorporating the water molecules to create a new material. The metal alloy can expand over 80% as it transforms into its final state as a rock-like seal.\u0000 Extensive small-scale and full-scale tests were conducted to reliably and consistently map the metamorphosis from the engineered metal alloy into the rock-like material. These tests required developing new methods for testing the material including designing new test fixtures and new test procedures. Testing proved seals were created in smooth cylinders as well as in irregular shapes and with a wide range of brine types and brine concentrations. The result is an expanding engineered alloy that creates a robust and durable seal with anchoring capabilities across a wide range of downhole conditions.\u0000 A novel non-elastomeric zonal isolation system is composed of a new expanding metal alloy that expands in water-ba","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"11 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127622755","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Pilot-Scale Experimental Study of Gas Migration in Wellbores","authors":"S. Rao, G. A. Samdani, G. Penny, Qian Wu, Angel Wileman, Griffin C. Beck, S. Bhagwat, V. Gupta","doi":"10.2118/210137-ms","DOIUrl":"https://doi.org/10.2118/210137-ms","url":null,"abstract":"\u0000 Gas migration velocity impacts the planning of pressurized mud cap drilling (PMCD) as it plays a pivotal role in the selection of fluid volumes and logistics. A pilot-scale experimental investigation of gas migration under downhole conditions (up to 3,600 psi, 240°F) in water, oils, and low-density drilling fluids is presented. While bubble-rise phenomena have been studied at near atmospheric pressures, the experimental setup and measurement method for high-temperature, high-pressure gas migration is rare. Experiments were performed using three test apparatuses: two separate pressurized lengths of 3-inch pipe, one 10-ft long and the other 18-ft long, as well as a unique high-pressure, high-temperature rotating test section (RTS). The RTS is 10-ft long, having a 6 inch × 4 inch eccentric annular geometry with the inner pipe capable of rotation. The inclination of all test sections can be varied. Gas was injected from the bottom through either a 1/8-inch diameter pressurized-injection port or a liquid-gas swap mechanism i.e. zero-velocity injection. Gas migration was recorded using a camera system or gamma-ray densitometers (GRDs). Some of the key results and insights from the testing are: (1) the gas migration rate and bubble length decrease with an increase in pressure, (2) the gas migration rate is higher in inclined vs. vertical sections, (3) bubble breakup occurs as pressure increases and interfacial tension decreases, (4) the inclination of the fluid column delays bubble breakup, and (5) high viscosity hinders bubble breakup. A key observation from the testing was that Taylor bubbles that may form during the initial phase of gas entering the annulus are likely to break up under downhole conditions of high pressure, low interfacial tension, and typical field mud viscosities, resulting in much lower gas migration rates during PMCD than the commonly used industry correlations. Another observation was that the practical length limitation of the test articles prevents us from observing the full evolution of gas bubble breakup. The results seen here are in line with our previous simulation work (Samdani et al., 2021, 2022).","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"63 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127888059","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}